Process for fluid catalytic cracking and hydrocracking hydrocarbons

ABSTRACT

A process and apparatus for recovering cycle oil from FCC CSO is described. By feeding the additional cycle oil to a hydrocracking unit additional diesel, naphtha and petrochemical feedstock may be obtained. The additional cycle oil is obtained by vacuum separation of the CSO. The described process and apparatus can provide additional recovery for a refiner.

BACKGROUND

The field of the invention is fluid catalytic cracking (FCC) andhydrocracking.

FCC technology, now more than 50 years old, has undergone continuousimprovement and remains the predominant source of gasoline production inmany refineries. This gasoline, as well as lighter products, is formedas the result of cracking heavier, less valuable hydrocarbon feed stockssuch as gas oil.

In its most general form, the FCC process comprises a reactor that isclosely coupled with a regenerator, followed by downstream hydrocarbonproduct separation. Hydrocarbon feed contacts catalyst in the reactor tocrack the hydrocarbons down to smaller molecular weight products. Duringthis process, coke tends to accumulate on the catalyst which is burnedoff in the regenerator.

The least valuable product from an FCC process is clarified slurry oil(CSO) which is withdrawn from the bottom of the FCC main fractionationcolumn and burned as fuel. The CSO comprises the heaviest product mixedwith catalyst particles that have not been successfully removed from theFCC products. Light Cycle Oil (LCO) is also produced in an FCC unit andcan be directed to the diesel pool. However, LCO may degrade the qualityof the diesel pool due to its high aromaticity and low cetane value. TheCSO is less valuable than Light Cycle Oil. Due to operationalconstraints of FCC main fractionation column, the CSO leaves the mainfractionator with an appreciable amount of hydrocarbons in the boilingrange of LCO and a small amount in the boiling range of gasoline. Heavycycle oil (HCO) is an FCC product pumped around to cool the mainfractionation column but is not often recovered from the mainfractionation column.

For FCC units experiencing coking in the main fractionation columnbottoms, the main column can be operated at a lower temperature byreducing the flow rate of LCO withdrawn from an LCO side outlet of themain fractionation column and increasing the flow rate of CSO withdrawnfrom the main fractionation column bottom. The additional LCO in CSOwill lower FCC main fractionation column temperature, reduce coking andmaintenance on FCC main column bottoms exchangers. However, the refinerwho operates with extra LCO in CSO bottoms stream to prevent maintenanceissues pays a penalty by losing the additional LCO in the CSO which isnot recovered.

Hydrocracking is a hydroprocessing process in which hydrocarbons crackat the carbon-carbon bonds in the presence of hydrogen and hydrocrackingcatalyst to lower molecular weight hydrocarbons. Depending on thedesired output, a hydrocracking unit may contain one or more fixed bedsof the same or different catalyst. Hydrotreating is a hydroprocessingprocess in which heteroatoms are removed from hydrocarbons and olefiniccompounds are saturated.

It would be desirable to recover useful hydrocarbons from CSO. It mayalso be desirable to upgrade the hydrocarbons recovered from CSO to makequality diesel.

SUMMARY OF THE INVENTION

In a process embodiment, the invention comprises a process forcatalytically cracking hydrocarbons comprising feeding a hydrocarbonfeed stream to an FCC reactor and contacting the hydrocarbon feed streamwith catalyst to catalytically crack the hydrocarbon feed stream toprovide a cracked stream. The catalyst is disengaged from the crackedstream which is fractionated into products including a slurry oil streamfrom a bottom of a main fractionation column. The slurry oil stream isseparated into a cycle oil stream and a heavy stream under vacuumpressure. At least a portion of the cycle oil stream is hydrocrackedover hydrocracking catalyst to provide an upgraded stream.

In an apparatus embodiment, the invention comprises an apparatus forproducing an upgraded product comprising an FCC reactor; a mainfractionation column in communication with the FCC reactor and aseparator in communication with a main bottoms line of the mainfractionation column. A receiver is in communication with a separatoroverhead line of the separator and a vacuum generating device is incommunication with a receiver overhead line of the receiver. A receiverbottoms line of the receiver provides a cycle oil process stream.

In an additional process embodiment, the invention comprises a processfor recovering catalytically cracked hydrocarbons comprising feeding ahydrocarbon feed stream to an FCC reactor and contacting the hydrocarbonfeed stream with catalyst to catalytically crack the hydrocarbon feedstream to provide a cracked stream. The catalyst is disengaged from thecracked stream which is fractionated into products including a slurryoil stream from a bottom of a main fractionation column. The slurry oilstream is separated into a separator overhead stream and a heavy streamunder vacuum pressure in a separator. The separator overhead stream iscondensed, and the condensed overhead stream is separated in a receiver.A cycle oil stream is recovered from a bottom of the receiver.

Advantageously, the process can enable recovery of LCO and/or HCO fromCSO to be used as motor fuel or further upgraded to make quality dieseland petrochemicals.

Additional features and advantages of the invention will be apparentfrom the description of the invention, figures and claims providedherein.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a schematic drawing of a FCC unit and a hydrocracking unit.

FIG. 2 is schematic drawing of an alternative embodiment of FIG. 1.

DEFINITIONS

The term “communication” means that material flow is operativelypermitted between enumerated components.

The term “downstream communication” means that at least a portion ofmaterial flowing to the subject in downstream communication mayoperatively flow from the object with which it communicates.

The term “upstream communication” means that at least a portion of thematerial flowing from the subject in upstream communication mayoperatively flow to the object with which it communicates.

The term “direct communication” means that flow from the upstreamcomponent enters the downstream component without undergoing acompositional change due to physical fractionation or chemicalconversion.

The term “bypass” means that the object is out of downstreamcommunication with a bypassing subject at least to the extent ofbypassing.

The term “column” means a distillation column or columns for separatingone or more components of different volatilities. Unless otherwiseindicated, each column includes a condenser on an overhead of the columnto condense and reflux a portion of an overhead stream back to the topof the column and a reboiler at a bottom of the column to vaporize andsend a portion of a bottoms stream back to the bottom of the column.Feeds to the columns may be preheated. The top pressure is the pressureof the overhead vapor at the vapor outlet of the column. The bottomstemperature is the liquid bottoms outlet temperature. Overhead lines andbottoms lines refer to the net lines from the column downstream of anyreflux or reboil to the column. Stripping columns omit a reboiler at abottom of the column and instead provide heating requirements andseparation impetus from a fluidized inert media such as steam.

As used herein, the term “True Boiling Point” (TBP) means a test methodfor determining the boiling point of a material which corresponds toASTM D-2892 for the production of a liquefied gas, distillate fractions,and residuum of standardized quality on which analytical data can beobtained, and the determination of yields of the above fractions by bothmass and volume from which a graph of temperature versus mass %distilled is produced using fifteen theoretical plates in a column witha 5:1 reflux ratio.

As used herein, the term “T5” or “T95” means the temperature at which 5volume percent or 95 volume percent, as the case may be, respectively,of the sample boils using ASTM D-86.

As used herein, the term “initial boiling point” (IBP) means thetemperature at which the sample begins to boil using ASTM D-86.

As used herein, the term “end point” (EP) means the temperature at whichthe sample has all boiled off using ASTM D-86.

As used herein, the term “diesel cut point” is between about 343° C.(650° F.) and about 399° C. (750° F.) using the TBP distillation method.

As used herein, the term “diesel boiling range” means hydrocarbonsboiling in the range of between about 132° C. (270° F.) and the dieselcut point using the TBP distillation method.

As used herein, the term “diesel conversion” means conversion of feedthat boils above the diesel cut point to material that boils at or belowthe diesel cut point in the diesel boiling range.

As used herein, the term “separator” means a vessel which has an inletand at least an overhead vapor outlet and a bottoms liquid outlet andmay also have an aqueous stream outlet from a boot. A flash drum is atype of separator which may be in downstream communication with aseparator that may be operated at higher pressure.

As used herein, the term “predominant” or “predominate” means greaterthan 50%, suitably greater than 75% and preferably greater than 90%.

As used herein, the term “a component-rich stream” means that the richstream coming out of a vessel has a greater concentration of thecomponent than the feed to the vessel.

DETAILED DESCRIPTION

An FCC unit and a hydrocracking unit are integrated to increase thevalue of the final products by recovering additional feed to thehydrocracking unit from the FCC clarified slurry oil (CSO) product.Cycle oil material in the CSO is separated and used as additional feedto the hydrocracking unit. A vacuum flash drum or vacuum column is usedto recover lighter material from the CSO. The recovered overhead productis then sent to the hydrocracking unit in order to make more dieseland/or petrochemical products. The additional feed is converted in thehydrocracking unit to additional lighter products such as gasoline,kerosene, diesel, ethylene, propylene and aromatics.

FIG. 1, wherein like numerals designate like components, illustrates anapparatus and process 8 that is equipped for processing a freshhydrocarbon feed stream. The apparatus and process 8 generally includean FCC unit 10, an FCC recovery section 50, a hydrocracking unit 100,and a hydrocracking recovery section 120.

The fresh hydrocarbon feed may be introduced in an FCC feed line 15. Aconventional FCC feedstock and higher boiling hydrocarbon feedstock aresuitable fresh hydrocarbon feed streams. The most common of suchconventional fresh hydrocarbon feedstocks is a “vacuum gas oil” (VGO),which is typically a hydrocarbon material having a boiling range with anIBP of around or about 340° C. (644° F.), a T5 between about 340° C.(644° F.) to about 350° C. (662° F.), a T95 between about 555° C. (1031°F.) and about 570° C. (1058° F.) and an EP of around or about 570° C.(1058° F.) prepared by vacuum fractionation of atmospheric residue. Sucha fraction is generally low in coke precursors and heavy metalcontamination which can serve to contaminate catalyst. Atmosphericresidue is a preferred feedstock boiling with an IBP of around or about340° C. (644° F.), a T5 between about 340° C. (644° F.) and about 360°C. (680° F.) and a T95 of between about 700° C. (1292° F.) and about900° C. (1652° F.) obtained from the bottom of an atmospheric crudedistillation column. Atmospheric residue is generally high in cokeprecursors and metal contamination. Other heavy hydrocarbon feedstockswhich may serve as fresh hydrocarbon feed include heavy bottoms fromcrude oil, heavy bitumen crude oil, shale oil, tar sand extract,deasphalted residue, products from coal liquefaction, vacuum reducedcrudes. Fresh hydrocarbon feedstocks also include mixtures of the abovehydrocarbons and the foregoing list is not comprehensive.

FIG. 1 shows a typical FCC unit 10 which includes an FCC reactor 12comprising a riser 20 and a catalyst regenerator 14. The FCC feed streamin the FCC feed line 15 is fed to the riser 20 via distributors 16 to becontacted with a regenerated cracking catalyst. Regenerated crackingcatalyst entering from a regenerated catalyst standpipe 18 is contactedwith the FCC feed stream in the riser 20 of the FCC reactor 12. In theriser 20 of the FCC reactor 12, the FCC feed stream is contacted withcatalyst to catalytically crack the FCC feed stream to provide a crackedstream.

The contacting of the FCC feed stream with cracking catalyst may occurin the riser 20 of the FCC reactor 12, extending upwardly to the bottomof a reactor vessel 22. The contacting of feed and catalyst is fluidizedby gas from a fluidizing line 24. Heat from the catalyst vaporizes theFCC feed stream, and the FCC feed stream is thereafter cracked tolighter molecular weight hydrocarbons in the presence of the crackingcatalyst as both are transferred up the riser 20 into the reactor vessel22. The cracked stream of hydrocarbon products in the riser 20 isthereafter disengaged from the cracking catalyst using cyclonicseparators which may include a rough cut separator 26 and one or twostages of cyclones 28 in the reactor vessel 22. A cracked stream ofproduct gases exit the reactor vessel 22 through a product outlet 31 toline 32 for transport to a downstream FCC recovery section 50.

The outlet temperature of the cracked products leaving the riser 20should be between about 472° C. (850° F.) and about 593° C. (1100° F.).Inevitable side reactions occur in the riser 20 leaving coke deposits onthe catalyst that lower catalyst activity. The spent or coked catalystrequires regeneration for further use. Coked catalyst, after separationfrom the gaseous cracked product hydrocarbons, falls into a strippingsection 34 where steam is injected through a nozzle 35 and distributorto purge any residual hydrocarbon vapor. After the stripping operation,the coked catalyst is fed to the catalyst regenerator 14 through a spentcatalyst standpipe 36.

FIG. 1 depicts a regenerator 14 known as a combustor. However, othertypes of regenerators are suitable. In the catalyst regenerator 14, astream of oxygen-containing gas, such as air, is introduced through anair distributor 38 to contact the coked catalyst, burn coke depositedthereon, and provide regenerated catalyst and flue gas. A stream of airor other oxygen containing gas is fed into the regenerator 14 throughline 37. Catalyst and air flow upwardly together along a combustor riser40 located within the catalyst regenerator 14 and, after regeneration,are initially separated by discharge through a disengager 42. Finerseparation of the regenerated catalyst and flue gas exiting thedisengager 42 is achieved using first and second stage separatorcyclones 44, 46, respectively, within the catalyst regenerator 14.Catalyst separated from flue gas dispenses through diplegs from cyclones44, 46 while flue gas significantly lighter in catalyst sequentiallyexits cyclones 44, 46 and exit the regenerator vessel 14 through fluegas outlet 47 in line 48. Regenerated catalyst is recycled back to thereactor riser 20 through the regenerated catalyst standpipe 18.

As a result of the coke burning, the flue gas vapors exiting at the topof the catalyst regenerator 14 in line 48 contain CO, CO₂ and H₂O, alongwith smaller amounts of other species. Catalyst regeneration temperatureis between about 500° C. (932° F.) and about 900° C. (1652° F.). Boththe cracking and regeneration occur at an absolute pressure betweenabout 0.5 and about 5 atmospheres.

In the FCC recovery section 50, the gaseous cracked stream in line 32 isfed to a lower section of an FCC main fractionation column 52. The mainfractionation column 52 is in downstream communication with the riser 20and the FCC reactor 12. Several fractions may be fractionated and takenfrom the main fractionation column 52 including a CSO stream from thebottom in main bottoms line 58, an optional heavy cycle oil (HCO) streamin line 54, an LCO in line 55 and an optional heavy naphtha stream inline 56. In FIG. 1, a heavy cycle oil (HCO) stream in line 54 may onlybe pumped around to cool the main fractionation column 52 without an HCOproduct stream being taken. Gasoline and gaseous light hydrocarbons areremoved in a main overhead line 57 from the main fractionation column 52and condensed before entering a main column receiver 59. An aqueousstream is removed from a boot in the receiver 59. Moreover, a condensedunstabilized, light naphtha stream is removed in a main column receiverbottoms line 61 while a gaseous light hydrocarbon stream is removed inoverhead line 62. A portion of the light naphtha stream in bottoms line61 may be refluxed to the main fractionation column 52 while a lightunstabilized naphtha stream is withdrawn in line 63. Both streams inlines 62 and 63 may enter a vapor recovery section downstream of themain fractionation column 52.

The light unstabilized naphtha fraction preferably has an initialboiling point (IBP) in the C₅ range; i.e., between about 24° C. (75° F.)and about 35° C. (95° F.), and an end point (EP) at a temperaturegreater than or equal to about 149° C. (300° F.). The optional heavynaphtha fraction has an IBP just above about 149° C. (300° F.) and an EPat a temperature above about 204° C. (400° F.), preferably between about200° C. (392° F.) and about 221° C. (430° F.). The LCO stream has an IBPof at least 149° C. (300° F.) if no heavy naphtha cut is taken or atabout the EP temperature of the heavy naphtha if a heavy naphtha cut istaken and an EP in a range of about 360° C. (680° F.) to about 382° C.(720° F.). The LCO stream may have a T5 in the range of about 213° C.(416° F.) to about 244° C. (471° F.) and a T95 in the range of about354° C. (669° F.) to about 377° C. (710° F.). The optional HCO streamhas an IBP just above the EP temperature of the LCO stream and an EP ina range of about 385° C. (725° F.) to about 482° C. (900° F.) andpreferably about 427° C. (800° F.). The HCO stream may have a T5 in therange of about 332° C. (630° F.) to about 349° C. (660° F.) and a T95 inthe range of about 382° C. (720° F.) to about 460° C. (860° F.) andpreferably about 404° C. (760° F.). The CSO stream has an IBP just abovethe EP temperature of the HCO stream or the LCO stream if the HCO streamis not taken and includes everything boiling at a higher temperature.Any or all of lines 54-56 may be cooled and pumped back to the maincolumn 52 to cool the main column typically at a higher location.

A vacuum separator 70 may be in downstream communication with the mainbottoms line 58 of the main fractionation column 52. In an aspect, aheater 68 such as a fired heater is on the main bottoms line 58 indownstream communication with the main bottoms line 58 and the mainfractionation column 52. The heater 68 can be used to heat the CSOstream to further prepare it for separation in the vacuum separator 70.The fired heater may heat the CSO stream to between about 371° C. (700°F.) to about 410° C. (770° F.). The vacuum separator is in downstreamcommunication with the heater 68. A feed inlet 58 i to the vacuumseparator 70 for the main bottoms line 58 admits CSO to the separator70.

The vacuum separator 70 may be a fractionation column with or without areboiler or it may be a simple one-stage flash separator. The vacuumseparator 70 separates the slurry oil stream into a cycle oil stream anda heavy stream under vacuum pressure of about 5 and about 25 kPa(absolute) and a temperature between about 332° C. (630° F.) to about354° C. (670° F.). The cycle oil stream may comprise at least somematerial boiling in the LCO range and/or at least some material boilingin the HCO range.

In an aspect, the cycle oil stream is comprised in a vaporous separatoroverhead stream transported in a separator overhead line 72 from a topof the vacuum separator 70 while the heavy stream is in a separatorbottoms stream transported in a separator bottoms line 74 from a bottomof the vacuum separator 70. An optional recycle line 75 may be indownstream communication with the separator bottoms line 74 and theseparator 70 may be in downstream communication with the recycle line.The recycle line 75 recycles a portion of the heavy stream from theseparator bottoms line 74 from a bottom of the separator 70 back to theseparator 70. The recycle line 75 recycles to a recycle inlet 75 i thatis above a feed inlet 58 i of the CSO stream to the separator 70. Thenet heavy stream comprising concentrated CSO is removed in line 77 andcan be sold as fuel oil or as feed to a coker unit or for carbon blackproduction.

A cooler 76 may be in downstream communication with the separatoroverhead line 72 for cooling and condensing the separator overheadstream. The condensed separator overhead stream enters a receiver 80 indownstream communication with the separator overhead line 72 from a topof the separator 70. The condensed overhead stream is separated in thereceiver 80 into the liquid cycle oil stream taken from a bottom of thereceiver 80 in a receiver bottoms line 82 and a vaporous receiveroverhead stream taken in receiver overhead line 78. The liquid cycle oilstream in the receiver bottoms line 82 is LCO and HCO rich and providesa cycle oil process stream which can be taken to an LCO pool, a dieselpool or to the hydrocracking unit 100 in hydroprocessing feed line 84.The receiver 80 may be operated under vacuum pressure of about 2 andabout 10 kPa (absolute) and a temperature between about 37° C. (100° F.)to about 149° C. (300° F.), preferably no more than about 121° C. (250°F.).

The cycle oil stream recovered in the hydroprocessing feed line 84 maycomprise about 5 to about 50 vol % and suitably about 20 to about 30 vol% of the CSO stream in main column bottoms line 58. Additionally, theAPI of the cycle oil stream in line 84 may decrease 1-5 and suitably 2-4API numbers relative to the CSO stream in main column bottoms line 58.

In an embodiment, if the vacuum separator 70 is a vacuum fractionationcolumn, the liquid cycle oil stream in receiver bottoms line may besplit between the cycle oil process stream in a hydroprocessing feedline 84 and a reflux stream in a reflux line 86 for reflux of a portionof the liquid cycle oil stream in the receiver bottoms line 82 from abottom of the receiver 80 to the vacuum separator 70 through the refluxinlet 86 i. The reflux line 86 may be in downstream communication withthe receiver bottoms line 82 and the vacuum separator 70, and the vacuumseparator may be in downstream communication with the reflux line 86.The reflux inlet 86 i to the vacuum separator 70 is for the reflux line86 which is at a higher elevation than the feed inlet 58 i to theseparator 70 for the main bottoms line 58 and a recycle inlet 75 i tothe separator 70 for the recycle line 75. In this embodiment, a packing71 may be disposed in the vacuum column between the recycle inlet 75 iand the reflux inlet 86 i. Refluxing the liquid cycle oil stream to thevacuum fractionation column enables control of the end point of thecycle oil process stream to satisfy feed requirements to downstreamunits, such as the hydrocracking unit 100.

The vacuum separator 70 is operated at below atmospheric pressure in theseparator overhead line 72. A vacuum generating device 88 such as aneductor or a vacuum pump is in downstream communication with thereceiver overhead line 78 of the receiver 80 for pulling a vacuum on thereceiver overhead stream from the receiver 80. In an embodiment, whenthe vacuum generating device 88 is an eductor, the eductor may be indownstream communication with an inert gas stream 89 such as steam whichpulls a vacuum on the receiver overhead stream in the receiver overheadline 78. The eductor feeds the inert gas stream mixed with the receiveroverhead stream to a condenser. The condensed mixture of the inert gasstream and the receiver overhead stream exit the condenser and enterinto a drain drum 90. A vaporous hydrocarbon stream in line 92 from thedrain drum 90 may be vented to flare or recovery. A condensed stream ofsour water may also be removed from the drain drum in drum bottoms line94 and taken to water treatment facilities for the FCC unit 10 which isnot described.

Because LCO may be recovered from the CSO stream in the main bottomsline 58, additional LCO may be allowed to flow into the CSO stream byreducing the LCO draw in line 55. This allows the main fractionationcolumn 52 to operate at lower bottoms temperature to prevent coking inthe main fractionation column. LCO is then recovered in the cycle oilprocess stream in hydroprocessing feed line 84 avoiding LCO loss andgiving more flexibility to the operation of the main fractionationcolumn 52.

The cycle oil process stream may be transported in the hydroprocessingfeed line 84 to the hydrocracking unit 100 to hydrocrack at least aportion of the cycle oil process stream over hydrocracking catalyst toprovide a diesel product stream and/or petrochemical feedstock. Thehydrocracking unit 100 may be in downstream communication with thereceiver bottoms line 82. The cycle oil process stream may be mixed withanother hydrocarbon feed stream in line 102 to provide a blendedhydrocracking feed stream in line 104. The other hydrocarbon feed streamin line 102 may be an LCO stream or it may comprise material having aninitial boiling point suitably no less than about 150° C. (302° F.) andpreferably no less than about 288° C. (550° F.), such as atmospheric gasoils, VGO, deasphalted, vacuum, and atmospheric residua, cokerdistillates, straight run distillates, solvent-deasphalted oils,pyrolysis-derived oils, high boiling synthetic oils, HCO, hydrocrackedfeeds, cat cracker distillates and the like. Suitable feeds may providean end point after being blended with the cycle oil process stream inhydroprocessing feed line 84 to provide the blended hydrocracking feedstream with an end point of no more than about 482° C. (900° F.),suitably no more than about 468° C. (875° F.) and preferably no morethan about 454° C. (850° F.). The T95 of the blended stream may be nomore than about 438° C. (820° F.), preferably about 448° C. (840° F.),to about 471° C. (880° F.), preferably about 460° C. (860° F.). Theblended hydrocracking feed stream may contain from about 0.1 to about 4wt % sulfur and 300 to 1800 wppm nitrogen. The blended hydrocrackingfeed stream may be heated, mixed with a hydrogen stream in line 106 andfed to the hydroprocessing vessel 110.

In an aspect of the present invention, the hydroprocessing vessel 110may include a hydrotreating reactor 112 to remove nitrogen and sulfurspecies and to saturate aromatic rings in the hydrocarbon feed stream.In the hydrotreating reactor, between about 60 to about 90 wt % andpreferably about 70 to about 80 wt % of the multi-ring aromatics may besaturated to have just one aromatic ring.

In an aspect, the hydrotreating reactor 112 may be a hydrotreatingcatalyst bed 112 b in the hydroprocessing vessel 110. Thehydroprocessing vessel 110 may comprise one or more vessels, multiplebeds of catalyst in each vessel, and various combinations ofhydrotreating catalyst, hydrocracking catalyst, hydrotreating reactorsand hydrocracking reactors in one or more vessels. The preheated,hydrocracking feed stream may be hydrotreated in the presence of thehydrogen stream and hydrotreating catalyst in one or more hydrotreatingcatalyst beds 112 b to provide a hydrotreated stream. The hydrotreatedstream and unconsumed hydrogen may be transferred to a hydrocrackingreactor 114 comprising a hydrocracking catalyst bed 114 b without anyseparation or heating. Hydrogen streams may be injected between or aftercatalyst beds to provide hydrogen requirements and/or to cool catalystbed effluent. For example, the hydroprocessing vessel 110 in FIG. 1 isillustrated to have three catalyst beds in one reactor vessel. From zeroto two hydrotreating catalyst beds 112 b of hydrotreating catalyst maybe followed by one to three hydrocracking catalyst beds 114 b inhydroprocessing vessel 110. Consequently, a hydrotreating reactor 112may be in downstream communication with the receiver bottoms line 82 andthe hydrocracking reactor 114 may be in downstream communication withthe hydrotreating reactor 112.

Typical hydrotreating conditions include an average hydrotreatingcatalyst bed temperature from about 260° C. (500° F.) to about 426° C.(800° F.), often from about 316° C. (600° F.) to about 426° C. (800°F.), and a hydrogen partial pressure from about 4.1 MPa (600 psig) toabout 10.5 MPa (1500 psig), often from about 6.2 MPa (800 psig) to about8.3 MPa (1400 psig). However, if the hydrotreating reactor 112 is in thesame hydroprocessing vessel 110 as the hydrocracking reactor 114,conditions in each will be closer to the same. A typical range of LHSVfor the hydrotreating reactor 112 is from about 0.1 to about 10 hr⁻¹,often from about 0.5 to about 3 hr⁻¹.

Suitable hydrotreating catalysts include those comprising of at leastone Group VIII metal, such as iron, cobalt, and nickel, cobalt and/ornickel, and at least one Group VI metal, such as molybdenum andtungsten, on a high surface area support material such as a refractoryinorganic oxide such as alumina and optionally with silica amounting tono more than 5 wt % silica. A representative hydrotreating catalysttherefore comprises a metal selected from the group consisting ofnickel, cobalt, tungsten, molybdenum, and mixtures thereof, such as amixture of cobalt and molybdenum, deposited on a refractory inorganicoxide support such as alumina.

The hydrotreated effluent stream or the hydrocracking feed stream ishydrocracked in the presence of hydrocracking catalyst and the hydrogenstream in the hydrocracking reactor 114 to provide a hydrocrackedeffluent stream in hydrocracked effluent line 116. In some aspects, thehydrocracking reaction provides diesel conversion of at least about 30vol % and typically no greater than about 60 vol % of the hydrocrackingfeed. At hydrocracking conditions, the feed is selectively converted toproducts such as diesel, kerosene, naphtha and gas to provide anupgraded product stream. Pressure may be moderate to allow opening ofall but one of the rings. As a result of being hydrocracked, theupgraded hydrocarbon product has a reduced average molecular weightrelative to the hydrocracker feed. For example, in the case of a blendedhydrocracking feed stream, in an aspect, prior to hydrotreating ispredominantly 2-ring aromatic compounds and multi-ring aromaticcompounds, the hydrocracked product may comprise at least about 40% byweight, and often at least about 50% by weight, mono-ring aromaticcompounds. In a preferred embodiment, the hydrocracked effluent streamcomprises or consists essentially of a mixture of the fuel componentsnaphtha and diesel fuel. In the hydrocracking reactor 114, between about60 to about 90 wt % and preferably about 70 to about 80 wt % of themulti-ring compounds may be cracked open to have just one ring intact.Also, due to desulfurization resulting from hydrotreating of all or aportion of the hydrocracking feed stream, the hydrocracked effluentstream may comprise or consist essentially of naphtha and diesel fuelthat meet sulfur specifications for ultra low sulfur naphtha and ultralow sulfur diesel.

Hydrocracking of the hydrocracking feed stream may be carried out in thepresence of a hydrocracking catalyst and hydrogen. Representativehydrocracking conditions include an average hydrocracking catalyst bedtemperature from about 260° C. (500° F.) to about 426° C. (800° F.),often from about 316° C. (600° F.) to about 426° C. (800° F.); ahydrogen partial pressure from about 4.1 MPa (600 psig) to about 10.5MPa (1500 psig), preferably from about 6.2 MPa (800 psig) to about 9.0MPa (1300 psig); an LHSV from about 0.1 hr⁻¹ to about 30 hr⁻¹, oftenfrom about 0.5 hr⁻¹ to about 3 hr⁻¹; and a hydrogen circulation ratefrom about 2000 standard ft³ per barrel (337 normal m3/m3) to about25,000 standard ft³ per barrel (4200 normal m3/m3), often from about5000 standard ft³ per barrel (840 normal m3/m3) to about 15,000 standardft³ per barrel (2530 normal m3/m3).

The hydrocracking catalysts may utilize amorphous silica-alumina and/orzeolite as cracking bases. A beta zeolite having a silica-to-aluminamolar ratio of less than 30:1 and an SF₆ adsorption capacity of at least28% may be a suitable cracking base. Cracking bases comprising amorphoussilica-alumina should have a silica content of 40 wt % or more

The zeolite cracking bases are sometimes referred to in the art asmolecular sieves and are usually composed of silica, alumina and one ormore exchangeable cations such as sodium, magnesium, calcium, rare earthmetals, etc. They are further characterized by crystal pores ofrelatively uniform diameter between about 4 and about 14 angstroms. Itis preferred to employ zeolites having a relatively highsilica-to-alumina molar ratio between about 3 and about 12. Suitablezeolites found in nature include, for example, mordenite, stilbite,heulandite, ferrierite, dachiardite, chabazite, erionite and faujasite.Suitable synthetic zeolites include, for example, the B, X, Y and Lcrystal types, e.g., synthetic faujasite and mordenite. The preferredzeolites are those having crystal pore diameters between about 8 to 12angstroms, wherein the silica-to-alumina molar ratio is about 4 to 6.One example of a zeolite falling in the preferred group is synthetic Ymolecular sieve.

The naturally occurring zeolites are normally found in a sodium form, analkaline earth metal form, or mixed forms. The synthetic zeolites arenearly always prepared first in the sodium form. In any case, for use asa cracking base it is preferred that most or all of the originalzeolitic monovalent metals be ion-exchanged with a polyvalent metaland/or with an ammonium salt followed by heating to decompose theammonium ions associated with the zeolite, leaving in their placehydrogen ions and/or exchange sites which have actually beendecationized by further removal of water. Hydrogen or “decationized” Yzeolites of this nature are more particularly described in U.S. Pat. No.3,130,006.

Mixed polyvalent metal-hydrogen zeolites may be prepared byion-exchanging first with an ammonium salt, then partially backexchanging with a polyvalent metal salt and then calcining. In somecases, as in the case of synthetic mordenite, the hydrogen forms can beprepared by direct acid treatment of the alkali metal zeolites. In oneaspect, the preferred cracking bases are those which are at least about10 wt %, and preferably at least about 20 wt %, metal-cation-deficient,based on the initial ion-exchange capacity. In another aspect, adesirable and stable class of zeolites is one wherein at least about 20wt % of the ion exchange capacity is satisfied by hydrogen ions.

The hydrogenation metals deposited on the base of the hydrocrackingcatalysts are those of Group VIII, i.e., iron, cobalt, nickel,ruthenium, rhodium, palladium, osmium, iridium and platinum. In additionto these metals, other promoters may also be employed in conjunctiontherewith, including the metals of Group VIB, e.g., molybdenum andtungsten. The amount of hydrogenation metal in the catalyst can varywithin wide ranges. Broadly speaking, any amount between about 0.05percent and about 30 percent by weight may be used. In the case of thenoble metals, it is normally preferred to use about 0.05 to about 2 wt%.

The foregoing catalysts may be employed in undiluted form, or thepowdered catalyst may be mixed and copelleted with other relatively lessactive catalysts, diluents or binders such as alumina, silica gel,silica-alumina cogels, activated clays and the like in proportionsranging between about 5 and about 90 wt %. These diluents may beemployed as such or they may contain a minor proportion of an addedhydrogenating metal such as a Group VIB and/or Group VIII metal.Additional metal promoted hydrocracking catalysts may also be utilizedin the process of the present invention which comprises, for example,aluminophosphate molecular sieves, MFI zeolites, crystallinechromosilicates and other crystalline silicates.

A hydrocracked effluent exits the hydrocracking reactor 114 in thehydrocracked effluent line 116. A hydrocracking recovery section 120 maybe provided in downstream communication with the hydrocracked effluentline 116. The hydrocracked effluent stream may be cooled and separatedin a hot separator 122. The hot separator 122 separates the hydrocrackedeffluent to provide a vaporous hydrocarbonaceous hot separator overheadstream in an overhead line 124 and a liquid hydrocarbonaceous hotseparator bottoms stream in a bottoms line 126. The hot separator 122 isin direct downstream communication with the hydrocracking reactor 114The hot separator 122 operates at about 177° C. (350° F.) to about 371°C. (700° F.). The hot separator 122 may be operated at a slightly lowerpressure than the hydrocracking reactor 114 accounting for pressure dropof intervening equipment.

The vaporous hydrocarbonaceous hot separator overhead stream in theoverhead line 124 may be cooled before entering a cold separator 130. Toprevent deposition of ammonium bisulfide or ammonium chloride salts inthe line 124 transporting the hot separator overhead stream, a suitableamount of wash water (not shown) may be introduced into line 124.

The cold separator 130 serves to separate hydrogen from hydrocarbon inthe hydrocracking effluent for recycle to the hydroprocessing reactorvessel 110. The vaporous hydrocarbonaceous hot separator overhead streammay be separated in the cold separator 130 to provide a vaporous coldseparator overhead stream comprising a hydrogen-rich gas stream in anoverhead line 132 and a liquid cold separator bottoms stream in thebottoms line 134. The cold separator 130, therefore, is in downstreamcommunication with the overhead line 124 of the hot separator 122. Thecold separator 130 may be operated at about 100° F. (38° C.) to about150° F. (66° C.) and just below the pressure of the hydrocrackingreactor 114 and the hot separator 122 accounting for pressure drop ofintervening equipment to keep hydrogen and light gases in the overheadand normally liquid hydrocarbons in the bottoms. The cold separator 130may also have a boot for collecting an aqueous phase in line 136.

The liquid hydrocarbonaceous stream in the hot separator bottoms line134 may be let down in pressure and flashed in a hot flash drum 140 toprovide a hot flash overhead stream of light ends in an overhead line142 and a heavy liquid stream in a hot flash bottoms line 144. The hotflash drum 126 may be operated at the same temperature as the hotseparator 122 but at a lower pressure. The heavy liquid stream inbottoms line 144 may be stripped of gases in a stripping column 160.

In an aspect, the liquid hydroprocessing effluent stream in the coldseparator bottoms line 134 may be let down in pressure and flashed in acold flash drum 150. The cold flash drum may be in downstreamcommunication with a bottoms line 134 of the cold separator 128. In afurther aspect, the vaporous hot flash overhead stream in overhead line142 may be cooled and also separated in the cold flash drum 150. Thecold flash drum 150 may separate the cold separator liquid bottomsstream in line 134 and the hot flash vaporous overhead stream inoverhead line 142 to provide a cold flash overhead stream of light endsin overhead line 152 and a cold flash bottoms stream in a bottoms line154. The cold flash bottoms stream in bottoms line 154 may be introducedto the stripping column 160. In an aspect, the stripping column 160 maybe in downstream communication with the cold flash bottoms line 154 andthe hot flash bottoms line 144.

The cold flash drum 150 may be in downstream communication with thebottoms line 134 of the cold separator 130, the overhead line 142 of thehot flash drum 140 and the hydrocracking reactor 114. In an aspect, thehot flash overhead line 142 joins the cold separator bottoms line 134which feeds the hot flash overhead stream and the cold separator bottomsstream together to the cold flash drum 150. The cold flash drum 150 maybe operated at the same temperature as the cold separator 130 buttypically at a lower pressure. The aqueous stream in line 136 from theboot of the cold separator 130 may also be directed to the cold flashdrum 150. A flashed aqueous stream is removed from a boot in the coldflash drum 150.

The vaporous cold separator overhead stream comprising hydrogen in theoverhead line 132 is rich in hydrogen. The cold separator overheadstream in overhead line 132 may be passed through a scrubbing tower 170to remove hydrogen sulfide and ammonia by use of an absorbent such as anamine absorbent. The scrubbed hydrogen-rich stream may be compressed ina recycle compressor 172 to provide a recycle hydrogen stream andsupplemented with a make-up hydrogen stream from line 174 to provide thehydrogen stream in hydrogen line 106.

The hot flash bottom stream in hot flash bottoms line 144 and the coldflash bottoms stream in the cold flash bottoms line 154 may be fed tothe stripper column 160 to be stripped of light gases such as hydrogensulfide. The cold flash bottoms stream may enter the stripping column160 at a higher elevation than the hot flash bottoms stream 154. Thehydrocracking effluent in the hot flash bottoms stream and the coldflash bottoms stream may be stripped in the stripping column 160 with astripping media which is an inert gas such as steam from line 162 toprovide an off-gas stream of hydrogen, hydrogen sulfide, steam and otherlight gases in an overhead line 164 for further treating. The strippercolumn 160 may be operated with a bottoms temperature between about 160°C. (320° F.) and about 360° C. (680° F.) and an overhead pressure ofabout 0.5 MPa (gauge) (73 psig) to about 2.0 MPa (gauge) (292 psig).

A stripped hydrocracked stream is produced in a stripper bottoms line166. At least a portion of the stripped hydrocracked stream in bottomsline 166 may be fed to a product fractionation column 180. Consequently,the product fractionation column 180 is in downstream communication withthe stripper bottoms line 166 of the stripper column 160.

The product fractionation column 180 may be in downstream communicationwith the hydrocracking reactor 114 for separating portions of thehydrocracking effluent stream into product streams. The hydroprocessingfractionation column 180 fractionates the stripped hydrocrackingeffluent by use of an inert stripping media such as steam from line 182.The product streams produced by the hydroprocessing fractionation column180 may include an overhead LPG stream in overhead line 184, a naphthastream in line 186, a kerosene stream carried in line 188 from a sideoutlet and a diesel stream in a bottoms line 190. If heavier feeds arefed to the hydroprocessing reactor 110, the diesel stream may bewithdrawn from an additional, optional side outlet in line 189 and anunconverted oil stream may be withdrawn in the bottoms line 190 whichmay be recycled to the FCC unit 10 or recycled to the hydroprocessingreactor 110. The fractionation overhead stream may be condensed andseparated in a receiver with a portion of the condensed liquid beingrefluxed back to the hydroprocessing fractionation column 180. The netnaphtha stream in line 186 may require further processing such as in anaphtha splitter column before blending in the gasoline pool or it maybe fed to a steam cracker for petrochemical production. The productfractionation column 180 may be operated with a bottoms temperaturebetween about 288° C. (550° F.) and about 370° C. (700° F.) and at anoverhead pressure between about 30 kPa (gauge) (4 psig) to about 200 kPa(gauge) (29 psig).

If aromatics recovery is desired over fuel production, portions of thenaphtha stream in line 186 and the diesel stream in line 189 or 190 fromthe product fractionation column 180 may routed to a transalkylationunit for the production of xylenes.

FIG. 2 illustrates an embodiment in which recovered light material isrecycled to the main column 52′. Many of the elements in FIG. 2 have thesame configuration as in FIG. 1 and bear the same reference number.Elements in FIG. 2 that correspond to elements in FIG. 1 but have adifferent configuration bear the same reference numeral as in FIG. 1 butare marked with a prime symbol (′).

In FIG. 2, a main fractionation column 52′ is in downstreamcommunication with the FCC reactor 10. A vacuum separator 70′ may be indownstream communication with a main bottoms line 58 of the mainfractionation column 52′. In an aspect, a heater 68 such as a firedheater may be on the main bottoms line 58 in downstream communicationwith the main bottoms line 58 and the main fractionation column 52′. Theheater 68 can be used to heat the CSO stream to further prepare it forseparation in the vacuum separator 70. The fired heater may heat the CSOstream to between about 371° C. (700° F.) to about 410° C. (770° F.).The vacuum separator 70′ is in downstream communication with the heater68. A feed inlet 58 i to said vacuum separator 70′ for the main bottomsline 58 admits CSO to the separator 70.

The vacuum separator 70 may be a fractionation column or it may be asimple one-stage flash separator. The vacuum separator 70′ separates theslurry oil stream into a cycle oil stream and a heavy stream undervacuum pressure of about 5 and about 25 kPa (absolute) and a temperaturebetween about 332° C. (630° F.) to about 354° C. (670° F.).

The heavy stream is transported from the separator 70′ in a separatorbottoms line 74′ and can be sold as fuel oil or as feed to a coker unitor to make carbon black. The cycle oil stream is comprised in anoverhead stream of the vacuum separator 70′ in a separator overhead line72. A cooler 76 is in downstream communication with the separatoroverhead line 72. The overhead stream is condensed in the cooler 76 andseparated in a receiver 80′.

The condensed separator overhead stream enters the receiver 80′ which isin downstream communication with the separator overhead line 72 of thevacuum separator 70′. The condensed overhead stream is separated in thereceiver 80′ into the liquid cycle oil stream taken from a bottom of thereceiver 80′ in a receiver bottoms line 82′. A vaporous receiveroverhead stream is taken in receiver overhead line 78. The liquid cycleoil stream in the receiver bottoms line 82′ is LCO and HCO rich andprovides a cycle oil process stream. The receiver 80′ may be operatedunder vacuum pressure of about 2 and about 10 kPa (absolute) and atemperature between about 37° C. (100° F.) to about 149° C. (300° F.),preferably no more than about 121° C. (250° F.).

The vacuum separator 70′ is operated at below atmospheric pressure inthe separator overhead line 72. A vacuum generating device 88 such as aneductor may be in downstream communication with the receiver overheadline 78 of the receiver 80 for pulling a vacuum on the receiver overheadstream from the receiver 80 as explained with respect to FIG. 1.

The embodiment of FIG. 2 has the main fractionation column 52′ indownstream communication with the vacuum separator 80′ and specificallywith the receiver bottoms line 82′ of the receiver 80′. The receiverbottoms line 82′ refluxes the cycle oil stream to the main fractionationcolumn 52′. A reflux inlet 82 i to the main fractionation column 52′ forthe receiver bottoms line 82′ may be in downstream communication withthe vacuum separator 70′. Additionally, the main fractionation column52′ also may be in downstream communication with the separator overheadline 72 of the vacuum separator 70′. The cycle oil process stream isre-fractionated in the main fractionation column to remove a heavy tailof higher boiling materials from the cycle oil process stream. Thereflux inlet 82 i may be located at an elevation above the bottom of themain fractionation column 52′ but at a lower elevation than a sideoutlet 54 o of the main fractionation column. The side outlet 54 o maybe for withdrawing a cycle oil stream from a side 53 of the mainfractionation column 52′ from the side outlet 54 o that is at a higherelevation than an inlet 82 i of the cycle oil process stream refluxed tothe main fractionation column. The side outlet 54 o is preferably aliquid draw of a liquid cycle oil stream from the main fractionationcolumn 52′.

The cycle oil stream may be withdrawn from the side 53 of the mainfractionation column 52′ in a cycle oil line 54′ and split into aportion in a return stream in a return line 57 and another portion in ahydroprocessing feed stream in a hydroprocessing feed line 84′. A returnline 57 to said main fractionation column may be in downstreamcommunication with the side outlet 54 o. A hydrocracking unit 100 is indownstream communication with the side outlet 54 o of the mainfractionation column 52′. The portion of the cycle oil stream from themain fractionation column 52′ in the hydroprocessing feed line 84′ maybe hydrocracked in the hydrocracking unit 100, and the other portion ofthe cycle oil stream in the return line may be returned to the mainfractionation column 52′. A cooler 65 on the return line 57 cools theother portion of the cycle oil stream comprising the return streambefore it is returned to the main fractionation column 52′ after thehydroprocessing feed stream in line 84′ is taken from the cycle oilstream in cycle oil line 54′.

The hydroprocessing feed stream comprising a cycle oil stream from themain fractionation column in hydroprocessing feed line 84′ may behydrocracked in the hydrocracking unit 100 as described with respect toFIG. 1. A hydrotreating reactor 112 may be in communication with theside outlet 54 o of the main fractionation column 52′ and ahydrocracking reactor 114 may be in downstream communication with saidhydrotreating reactor 112. As explained with respect to FIG. 1, a dieselstream and/or an aromatics stream may be recovered from the hydrocrackedcycle oil stream. All aspects of the embodiments of FIG. 1 areapplicable to FIG. 2 unless stated otherwise.

EXAMPLES Example 1

The described embodiment was simulated to demonstrate its usefulness.The first base case refinery sends hydrotreated atmospheric resid feedto an FCC unit at a rate of 603 m³/h with 166 m³/h of LCO and dieselthat is fed to a hydrocracking unit. The base case refinery is equippedto upgrade and produce aromatics or feedstock for a steam cracker formaking ethylene and propylene. By using a vacuum column or vacuum flashdrum to recover light material from FCC, CSO product, approximately 25vol % of cycle oil material can be recovered relative to the CSOproduct. The cycle oil material is then sent to the hydrocracking unit,to increase hydrocracking unit feed rate by 3.0 vol % to 171 m³/h. Dueto the increased feed rate to the hydrocracking unit, total productyield from the steam cracker for light olefins and the hydrocrackingunit for aromatics will increase as shown in Table 1.

TABLE 1 Stream Increase, wt % Hydrocracking feed 3.4 Ethylene 3.8Propylene 3.9 Benzene 4.1 Toluene 4.1 Xylenes 4.1

Example 2

In a second base case, the refinery is equipped for fuels production.The second base case refinery sends hydrotreated atmospheric resid feedto an FCC unit at a rate of 576 m³/h with 364 m3/h of LCO and dieselthat is fed to a hydrocracking unit. By using a vacuum column or vacuumflash drum to recover light material from FCC, CSO product,approximately 25 vol % of cycle oil material can be recovered relativeto the CSO product. The light material is then sent to the hydrocrackingunit, to increase hydrocracking unit feed rate by 1.3 vol % to 369 m³/h.Due to the increased feed rate to the hydrocracking unit, total productyield from the hydrocracking unit will increase as shown in Table 2.

TABLE 2 Stream Increase, wt % Hydrocracking feed 1.5 95 RON Euro VGasoline 2.5 Kerosene/Jet Fuel 1.3 Euro V Diesel 0.9 LPG 4.1

Example 3

Various embodiments of the present invention were simulated to assessthe additional feed produced for the hydrocracking unit.

In a first simulation, 38,208 kg/hr of CSO at 363° C. (685° F.) is fedto a vacuum flash drum.

In a second simulation, the same feed is sent to a vacuum fractionationcolumn without a reboiler. A reflux stream of 1,956 kg/hr of a liquidcycle oil stream taken from a bottom of the overhead receiver in areceiver bottoms line is refluxed to the vacuum fractionation column.

In a third simulation, the same feed is heated to 382° C. (720° F.) in afired heater before being fed to a vacuum fractionation column and areflux stream of only 1059 kg/hr a liquid cycle oil stream taken from abottom of the overhead receiver in a receiver bottoms line is refluxedto the vacuum fractionation column.

In a fourth simulation, 38,301 kg/hr of CSO at 363° C. (685° F.) is fedto a vacuum flash drum, but 5,777 kghr of the cycle oil process streamfrom the overhead receiver bottoms is refluxed to the main fractionationcolumn. The hydrocracking feed is taken as a portion of the HCO streamwithdrawn from a side of the main fractionation column.

A comparison of the additional cycle oil, hydrocracking feeds are shownin Table 3. Boiling point properties are provided using TBP.

TABLE 3 Flow rate, Fraction of T95, End Point, Simulation kg/hr CSO, wt% ° C. ° C. 1 7584 20 490 557 2 2083 5 416 448 3 8614 23 471 510 4 577715 419 456

These embodiments produce suitable hydrocracking feedstock insubstantial quantities that may be hydrocracked alone or blended withother hydrocracking feed for hydrocracking to upgraded products.

SPECIFIC EMBODIMENTS

While the following is described in conjunction with specificembodiments, it will be understood that this description is intended toillustrate and not limit the scope of the preceding description and theappended claims.

A first embodiment of the invention is a process for catalyticallycracking hydrocarbons comprising feeding a hydrocarbon feed stream to anFCC reactor and contacting the hydrocarbon feed stream with catalyst tocatalytically crack the hydrocarbon feed stream to provide a crackedstream; disengaging the catalyst from the cracked stream; fractionatingthe cracked stream into products including a slurry oil stream from abottom of a main fractionation column; separating the slurry oil streaminto a cycle oil stream and a heavy stream under vacuum pressure; andhydrocracking at least a portion of the cycle oil stream overhydrocracking catalyst to provide an upgraded stream. An embodiment ofthe invention is one, any or all of prior embodiments in this paragraphup through the first embodiment in this paragraph further comprisingheating the slurry oil stream before the separation step. An embodimentof the invention is one, any or all of prior embodiments in thisparagraph up through the first embodiment in this paragraph furthercomprising recycling a portion of the heavy stream to the separationstep. An embodiment of the invention is one, any or all of priorembodiments in this paragraph up through the first embodiment in thisparagraph further comprising recycling a portion of the heavy streamfrom a separator bottoms line to a recycle inlet that is above an inletof the slurry oil stream to the separator. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the first embodiment in this paragraph further comprisingcondensing a separator overhead stream from an overhead of theseparator, separating the condensed overhead stream in a receiver andtaking the cycle oil stream from a bottom of a receiver. An embodimentof the invention is one, any or all of prior embodiments in thisparagraph up through the first embodiment in this paragraph furthercomprising pulling a vacuum on a receiver overhead stream from thereceiver and feeding it to a drain drum. An embodiment of the inventionis one, any or all of prior embodiments in this paragraph up through thefirst embodiment in this paragraph further comprising refluxing aportion of the cycle oil stream to the separator vessel to a refluxinlet that is above the recycle inlet. An embodiment of the invention isone, any or all of prior embodiments in this paragraph up through thefirst embodiment in this paragraph wherein the hydrocracking step isconducted in a hydrocracking reactor in which hydrocracking is thepredominant reaction. An embodiment of the invention is one, any or allof prior embodiments in this paragraph up through the first embodimentin this paragraph further comprising increasing a yield of dieselcompared to a yield without hydrocracking the cycle oil stream.

A second embodiment of the invention is a process for catalyticallycracking hydrocarbons comprising feeding a hydrocarbon feed stream to anFCC reactor and contacting the hydrocarbon feed stream with catalyst tocatalytically crack the hydrocarbon feed stream to provide a crackedstream; disengaging the catalyst from the cracked stream; fractionatingthe cracked stream into products including a slurry oil stream from abottom of a main fractionation column; separating the slurry oil streaminto a separator overhead stream and a heavy stream under vacuumpressure in a separator vessel; condensing the separator overheadstream; separating the condensed overhead stream in a receiver; takingthe cycle oil stream from a bottom of the receiver; and hydrocracking atleast a portion of the cycle oil stream over hydrocracking catalyst toprovide an upgraded product stream. An embodiment of the invention isone, any or all of prior embodiments in this paragraph up through thesecond embodiment in this paragraph further comprising heating theslurry oil stream before the separation step. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the second embodiment in this paragraph further comprisingrecycling the heavy stream to the separation step. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the second embodiment in this paragraph further comprisingrecycling a portion of the heavy stream from a bottom of a separatorvessel to a recycle inlet that is above an inlet of the slurry oilstream to the separator vessel. An embodiment of the invention is one,any or all of prior embodiments in this paragraph up through the secondembodiment in this paragraph further comprising pulling a vacuum on areceiver overhead stream from the receiver and feeding it to a draindrum. An embodiment of the invention is one, any or all of priorembodiments in this paragraph up through the second embodiment in thisparagraph further comprising refluxing a portion of the cycle oil streamto the separator vessel to a reflux inlet that is above the recycleinlet. An embodiment of the invention is one, any or all of priorembodiments in this paragraph up through the second embodiment in thisparagraph wherein the hydrocracking step is conducted in a hydrocrackingreactor in which hydrocracking is the predominant reaction. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the second embodiment in this paragraphfurther comprising increasing a yield of diesel compared to a yieldwithout hydrocracking the cycle oil stream.

A third embodiment of the invention is a process for catalyticallycracking hydrocarbons comprising feeding a hydrocarbon feed stream to anFCC reactor and contacting the hydrocarbon feed stream with catalyst tocatalytically crack the hydrocarbon feed stream to provide a crackedstream; disengaging the catalyst from the cracked stream; fractionatingthe cracked stream into products including a slurry oil stream from abottom of a main fractionation column; separating the slurry oil streaminto a cycle oil stream and a heavy stream under vacuum pressure in aseparator vessel; recycling the heavy stream to the separation step; andhydrocracking at least a portion of the cycle oil stream overhydrocracking catalyst to provide an upgraded product stream. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the third embodiment in this paragraph furthercomprising condensing a separator overhead stream from a separatorvessel; separating the condensed overhead stream in a receiver; andtaking the cycle oil stream from a bottom of the receiver. An embodimentof the invention is one, any or all of prior embodiments in thisparagraph up through the third embodiment in this paragraph furthercomprising pulling a vacuum on a receiver overhead stream from thereceiver.

A fourth embodiment of the invention is an apparatus for producing anupgraded product comprising an FCC reactor; a main fractionation columnin communication with the FCC reactor; a separator in communication witha main bottoms line of the main fractionation column; a receiver incommunication with a separator overhead line of the separator; a vacuumgeneration device in communication with a receiver overhead line of thereceiver; and a receiver bottoms line of the receiver for providing anHCO process stream. An embodiment of the invention is one, any or all ofprior embodiments in this paragraph up through the fourth embodiment inthis paragraph further comprising a hydrocracking unit in communicationwith the receiver bottoms line. An embodiment of the invention is one,any or all of prior embodiments in this paragraph up through the fourthembodiment in this paragraph further comprising a hydrotreating reactorin communication with the receiver bottoms line and a hydrocrackingreactor is in downstream communication with the hydrotreating reactor.An embodiment of the invention is one, any or all of prior embodimentsin this paragraph up through the fourth embodiment in this paragraphwherein the separator is a vacuum fractionation column. An embodiment ofthe invention is one, any or all of prior embodiments in this paragraphup through the fourth embodiment in this paragraph further comprising arecycle line in downstream communication with a separator bottoms lineand the separator is in downstream communication with the recycle line.An embodiment of the invention is one, any or all of prior embodimentsin this paragraph up through the fourth embodiment in this paragraphfurther comprising a recycle inlet to the separator for the recycleline, the recycle inlet being at a higher elevation than a feed inlet tothe separator for the main bottoms line. An embodiment of the inventionis one, any or all of prior embodiments in this paragraph up through thefourth embodiment in this paragraph further comprising a reflux line incommunication with the receiver bottoms line and the separator is indownstream communication with the reflux line. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the fourth embodiment in this paragraph further comprising areflux inlet to the separator for the reflux line, the reflux inletbeing at a higher elevation than a feed inlet to the separator for themain bottoms line and than a recycle inlet to the separator for therecycle line. An embodiment of the invention is one, any or all of priorembodiments in this paragraph up through the fourth embodiment in thisparagraph further comprising a heater in downstream communication withthe main fractionation column and the separator is in downstreamcommunication with the heater. An embodiment of the invention is one,any or all of prior embodiments in this paragraph up through the fourthembodiment in this paragraph further comprising a condenser incommunication with a separator overhead line.

A fifth embodiment of the invention is an apparatus for producing anupgraded product comprising an FCC reactor; a main fractionation columnin communication with the FCC reactor; a separator in communication witha main bottoms line of the main fractionation column; a receiver incommunication with a separator overhead line of the separator; aneductor in communication with a receiver overhead line of the receiver;a receiver bottoms line of the receiver for providing a HCO processstream; and a hydrocracking unit in downstream communication with thereceiver bottoms line. An embodiment of the invention is one, any or allof prior embodiments in this paragraph up through the fifth embodimentin this paragraph further comprising a hydrotreating reactor incommunication with the receiver bottoms line and a hydrocracking reactoris in downstream communication with the hydrotreating reactor. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the fifth embodiment in this paragraph whereinthe separator is a vacuum fractionation column. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the fifth embodiment in this paragraph further comprising arecycle line in downstream communication with a separator bottoms lineand the separator is in downstream communication with the recycle line.An embodiment of the invention is one, any or all of prior embodimentsin this paragraph up through the fifth embodiment in this paragraphfurther comprising a reflux line in communication with the receiverbottoms line and the separator is in downstream communication with thereflux line.

A sixth embodiment of the invention is an apparatus for producing anupgraded product comprising an FCC reactor; a main fractionation columnin communication with the FCC reactor; a separator in communication witha main bottoms line of the main fractionation column; and ahydrocracking unit in downstream communication with the separator. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the sixth embodiment in this paragraph furthercomprising a receiver in communication with a separator overhead line ofthe separator and the hydrocracking unit is in downstream communicationwith a receiver bottoms line of the receiver. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the sixth embodiment in this paragraph further comprising aneductor in communication with a receiver overhead line of the receiver.An embodiment of the invention is one, any or all of prior embodimentsin this paragraph up through the sixth embodiment in this paragraphwherein the separator is a vacuum fractionation column. An embodiment ofthe invention is one, any or all of prior embodiments in this paragraphup through the sixth embodiment in this paragraph further comprising arecycle line in downstream communication with a separator bottoms lineand the separator is in downstream communication with the recycle line.

A seventh embodiment of the invention is a process for recoveringcatalytically cracked hydrocarbons comprising feeding a hydrocarbon feedstream to an FCC reactor and contacting the hydrocarbon feed stream withcatalyst to catalytically crack the hydrocarbon feed stream to provide acracked stream; disengaging the catalyst from the cracked stream;fractionating the cracked stream into products including a slurry oilstream from a bottom of a main fractionation column; separating theslurry oil stream into a separator overhead stream and a heavy streamunder vacuum pressure in a separator; condensing the separator overheadstream; separating the condensed overhead stream in a receiver; andrecovering a cycle oil stream from a bottom of the receiver. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the seventh embodiment in this paragraphfurther comprising heating the slurry oil stream before the separationstep. An embodiment of the invention is one, any or all of priorembodiments in this paragraph up through the seventh embodiment in thisparagraph further comprising recycling a portion of the heavy stream tothe separation step. An embodiment of the invention is one, any or allof prior embodiments in this paragraph up through the seventh embodimentin this paragraph further comprising recycling a portion of the heavystream from a bottom of a separator vessel to a recycle inlet to theseparator vessel that is above an inlet of the slurry oil stream. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the seventh embodiment in this paragraphfurther comprising refluxing a portion of the cycle oil stream to areflux inlet to the separator vessel that is above the recycle inlet. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the seventh embodiment in this paragraphfurther comprising pulling a vacuum on a receiver overhead stream fromthe receiver and feeding it to a drain drum. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the seventh embodiment in this paragraph further comprisingrefluxing a portion of the cycle oil stream to the separator vessel. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the seventh embodiment in this paragraphfurther comprising recycling a portion of the heavy stream from a bottomof a separator vessel to a recycle inlet to the separator vessel that isabove an inlet of the slurry oil stream and refluxing the portion of thecycle oil stream to a reflux inlet to the separator vessel that is abovethe recycle inlet. An embodiment of the invention is one, any or all ofprior embodiments in this paragraph up through the seventh embodiment inthis paragraph further comprising recovering the heavy stream with anAPI that is lower than the slurry oil stream and producing carbon blackfeedstock. An embodiment of the invention is one, any or all of priorembodiments in this paragraph up through the seventh embodiment in thisparagraph further comprising recovering diesel from the cycle oilstream.

An eighth embodiment of the invention is a process for recoveringcatalytically cracking hydrocarbons comprising feeding a hydrocarbonfeed stream to an FCC reactor and contacting the hydrocarbon feed streamwith catalyst to catalytically crack the hydrocarbon feed stream toprovide a cracked stream; disengaging the catalyst from the crackedstream; fractionating the cracked stream into products including aslurry oil stream from a bottom of a main fractionation column;separating the slurry oil stream into a separator overhead stream and aheavy stream under vacuum pressure in a separator vessel; condensing theseparator overhead stream; separating the condensed overhead stream in areceiver; recovering a cycle oil stream from a bottom of the receiver;and obtaining an upgraded stream from the cycle oil stream. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the eighth embodiment in this paragraphfurther comprising heating the slurry oil stream before the separationstep. An embodiment of the invention is one, any or all of priorembodiments in this paragraph up through the eighth embodiment in thisparagraph further comprising recycling a portion of the heavy stream tothe separation step. An embodiment of the invention is one, any or allof prior embodiments in this paragraph up through the eighth embodimentin this paragraph further comprising recycling a portion of the heavystream from a bottom of a separator vessel to a recycle inlet to theseparator vessel that is above an inlet of the slurry oil stream. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the eighth embodiment in this paragraphfurther comprising refluxing a portion of the cycle oil stream to areflux inlet to the separator vessel that is above the recycle inlet. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the eighth embodiment in this paragraphfurther comprising pulling a vacuum on a receiver overhead stream fromthe receiver and feeding it to a drain drum. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the eighth embodiment in this paragraph further comprisingrefluxing a portion of the cycle oil stream to the separator vessel.

A ninth embodiment of the invention is a process for recoveringcatalytically cracked hydrocarbons comprising feeding a hydrocarbon feedstream to an FCC reactor and contacting the hydrocarbon feed stream withcatalyst to catalytically crack the hydrocarbon feed stream to provide acracked stream; disengaging the catalyst from the cracked stream;fractionating the cracked stream into products including a slurry oilstream from a bottom of a main fractionation column; separating theslurry oil stream into a separator overhead stream and a heavy streamunder vacuum pressure in a separator vessel; condensing the separatoroverhead stream; separating the condensed overhead stream in a receiver;recovering a cycle oil stream from a bottom of the receiver; pulling avacuum on a receiver overhead stream from the receiver; and obtaining anupgraded stream from the cycle oil stream. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the ninth embodiment in this paragraph further comprisingheating the slurry oil stream before the separation step. An embodimentof the invention is one, any or all of prior embodiments in thisparagraph up through the ninth embodiment in this paragraph furthercomprising recovering the heavy stream with an API that is lower thanthe slurry oil stream and producing carbon black feedstock.

A tenth embodiment of the invention is a process for catalyticallycracking hydrocarbons comprising feeding a hydrocarbon feed stream to anFCC reactor and contacting the hydrocarbon feed stream with catalyst tocatalytically crack the hydrocarbon feed stream to provide a crackedstream; disengaging the catalyst from the cracked stream; fractionatingthe cracked stream into products including a slurry oil stream from abottom of a main fractionation column; separating the slurry oil streaminto a cycle oil process stream and a heavy stream under vacuum pressurein a separator; and refluxing the cycle oil process stream to the mainfractionation column. An embodiment of the invention is one, any or allof prior embodiments in this paragraph up through the tenth embodimentin this paragraph further comprising hydrocracking a cycle oil streamfrom the main fractionation column. An embodiment of the invention isone, any or all of prior embodiments in this paragraph up through thetenth embodiment in this paragraph further comprising heating the slurryoil stream before the separation step. An embodiment of the invention isone, any or all of prior embodiments in this paragraph up through thetenth embodiment in this paragraph further comprising condensing aseparator overhead stream from an overhead of the separator, separatingthe condensed overhead stream in a receiver and taking the cycle oilprocess stream from a bottom of the receiver. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the tenth embodiment in this paragraph further comprisingpulling a vacuum on a receiver overhead stream from the receiver andfeeding it to a drain drum. An embodiment of the invention is one, anyor all of prior embodiments in this paragraph up through the tenthembodiment in this paragraph further comprising withdrawing a cycle oilstream from the main fractionation column, hydrocracking a portion ofthe cycle oil stream and returning another portion of the cycle oilstream to main fractionation column. An embodiment of the invention isone, any or all of prior embodiments in this paragraph up through thetenth embodiment in this paragraph further comprising withdrawing thecycle oil stream from the main fractionation column from an outlet thatis at a higher elevation than an inlet of the cycle oil process streamrefluxed to the main fractionation column. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the tenth embodiment in this paragraph further comprisingcooling the another portion of the cycle oil stream before it isreturned to the main fractionation column. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the tenth embodiment in this paragraph further comprisingrecovering a diesel stream and/or an aromatics stream from thehydrocracked cycle oil stream.

An eleventh embodiment of the invention is a process for catalyticallycracking hydrocarbons comprising feeding a hydrocarbon feed stream to anFCC reactor and contacting the hydrocarbon feed stream with catalyst tocatalytically crack the hydrocarbon feed stream to provide a crackedstream; disengaging the catalyst from the cracked stream; fractionatingthe cracked stream into products including a slurry oil stream from abottom of a main fractionation column; separating the slurry oil streaminto a cycle oil process stream and a heavy stream under vacuum pressurein a separator; and refluxing the cycle oil process stream to the mainfractionation column; and hydrocracking a cycle oil stream from the mainfractionation column. An embodiment of the invention is one, any or allof prior embodiments in this paragraph up through the eleventhembodiment in this paragraph further comprising condensing a separatoroverhead stream from an overhead of the separator, separating thecondensed overhead stream in a receiver and taking the cycle oil processstream from a bottom of the receiver. An embodiment of the invention isone, any or all of prior embodiments in this paragraph up through theeleventh embodiment in this paragraph further comprising pulling avacuum on a receiver overhead stream from the receiver and feeding it toa drain drum. An embodiment of the invention is one, any or all of priorembodiments in this paragraph up through the eleventh embodiment in thisparagraph further comprising withdrawing a cycle oil stream from themain fractionation column, hydrocracking a portion of the cycle oilstream and returning another portion of the cycle oil stream to mainfractionation column. An embodiment of the invention is one, any or allof prior embodiments in this paragraph up through the eleventhembodiment in this paragraph further comprising withdrawing the cycleoil stream from the main fractionation column from an outlet that is ata higher elevation than an inlet of the cycle oil process streamrefluxed to the main fractionation column. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the eleventh embodiment in this paragraph further comprisingrecovering a diesel stream and/or an aromatics stream from thehydrocracked cycle oil stream.

A twelfth embodiment of the invention is a process for catalyticallycracking hydrocarbons comprising feeding a hydrocarbon feed stream to anFCC reactor and contacting the hydrocarbon feed stream with catalyst tocatalytically crack the hydrocarbon feed stream to provide a crackedstream; disengaging the catalyst from the cracked stream; fractionatingthe cracked stream into products including a slurry oil stream from abottom of a main fractionation column; separating the slurry oil streaminto a cycle oil process stream and a heavy stream under vacuum pressurein a separator; refluxing the cycle oil process stream to the mainfractionation column; hydrocracking a cycle oil stream from the mainfractionation column; and recovering a diesel stream and/or an aromaticsstream from the hydrocracked cycle oil stream. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the twelfth embodiment in this paragraph further comprisingcondensing a separator overhead stream from an overhead of theseparator, separating the condensed overhead stream in a receiver andtaking the cycle oil process stream from a bottom of the receiver. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the twelfth embodiment in this paragraphfurther comprising withdrawing the cycle oil stream from the mainfractionation column, hydrocracking a portion of the cycle oil streamand returning another portion of the cycle oil stream to mainfractionation column.

A thirteenth embodiment of the invention is an apparatus for producingupgraded product comprising an FCC reactor; a main fractionation columnin communication with the FCC reactor; a vacuum separator incommunication with a main bottoms line of the main fractionation column;and a hydrocracking unit in communication with a side outlet of the mainfractionation column. An embodiment of the invention is one, any or allof prior embodiments in this paragraph up through the thirteenthembodiment in this paragraph wherein the main fractionation column is indownstream communication with the vacuum separator. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the thirteenth embodiment in this paragraph further comprising areflux inlet to the main fractionation column in downstreamcommunication with the vacuum separator, the reflux inlet being at alower elevation than the side outlet of the main fractionation column.An embodiment of the invention is one, any or all of prior embodimentsin this paragraph up through the thirteenth embodiment in this paragraphwherein the main fractionation column is in downstream communicationwith a separator overhead line of the vacuum separator. An embodiment ofthe invention is one, any or all of prior embodiments in this paragraphup through the thirteenth embodiment in this paragraph furthercomprising a receiver in communication with a separator overhead line ofthe vacuum separator; and the main fractionation column in downstreamcommunication with a receiver bottoms line of the receiver. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the thirteenth embodiment in this paragraphwherein the reflux inlet to the main fractionation column is for thereceiver bottoms line. An embodiment of the invention is one, any or allof prior embodiments in this paragraph up through the thirteenthembodiment in this paragraph further comprising a cooler incommunication with a separator overhead line. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the thirteenth embodiment in this paragraph further comprisingan eductor in communication with a receiver overhead line of thereceiver. An embodiment of the invention is one, any or all of priorembodiments in this paragraph up through the thirteenth embodiment inthis paragraph further comprising a hydrotreating reactor incommunication with the side outlet of the main fractionation column anda hydrocracking reactor is in downstream communication with thehydrotreating reactor. An embodiment of the invention is one, any or allof prior embodiments in this paragraph up through the thirteenthembodiment in this paragraph further comprising a return line to themain fractionation column in communication with the side outlet. Anembodiment of the invention is one, any or all of prior embodiments inthis paragraph up through the thirteenth embodiment in this paragraphfurther comprising a cooler on the return line. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the thirteenth embodiment in this paragraph further comprising aheater in downstream communication with the main fractionation columnand the vacuum separator is in downstream communication with the heater.

A fourteenth embodiment of the invention is an apparatus for producingupgraded product comprising an FCC reactor; a main fractionation columnin communication with the FCC reactor; a vacuum separator incommunication with a main bottoms line of the main fractionation column;the main fractionation column in downstream communication with thevacuum separator; and a hydrocracking unit in communication with a sideoutlet of the main fractionation column. An embodiment of the inventionis one, any or all of prior embodiments in this paragraph up through thefourteenth embodiment in this paragraph further comprising a refluxinlet to the main fractionation column in downstream communication withthe vacuum separator, the reflux inlet being at a lower elevation thanthe side outlet of the main fractionation column. An embodiment of theinvention is one, any or all of prior embodiments in this paragraph upthrough the fourteenth embodiment in this paragraph wherein the mainfractionation column is in downstream communication with a separatoroverhead line of the vacuum separator. An embodiment of the invention isone, any or all of prior embodiments in this paragraph up through thefourteenth embodiment in this paragraph further comprising a receiver incommunication with a separator overhead line of the vacuum separator;and the main fractionation column in downstream communication with areceiver bottoms line of the receiver.

A fifteenth embodiment of the invention is an apparatus for producingupgraded product comprising an FCC reactor; a main fractionation columnin communication with the FCC reactor; a vacuum separator incommunication with a main bottoms line of the main fractionation column;the main fractionation column in downstream communication with aseparator overhead line of the vacuum separator; and a hydrocrackingunit in communication with a side outlet of the main fractionationcolumn. An embodiment of the invention is one, any or all of priorembodiments in this paragraph up through the fifteenth embodiment inthis paragraph further comprising a reflux inlet to the mainfractionation column in downstream communication with the vacuumseparator, the reflux inlet being at a lower elevation than the sideoutlet of the main fractionation column. An embodiment of the inventionis one, any or all of prior embodiments in this paragraph up through thefifteenth embodiment in this paragraph further comprising a receiver incommunication with the separator overhead line of the vacuum separator;and the main fractionation column in downstream communication with areceiver bottoms line of the receiver. An embodiment of the invention isone, any or all of prior embodiments in this paragraph up through thefifteenth embodiment in this paragraph further comprising ahydrotreating reactor in communication with the side outlet of the mainfractionation column and a hydrocracking reactor is in downstreamcommunication with the hydrotreating reactor.

Without further elaboration, it is believed that using the precedingdescription that one skilled in the art can utilize the presentinvention to its fullest extent and easily ascertain the essentialcharacteristics of this invention, without departing from the spirit andscope thereof, to make various changes and modifications of theinvention and to adapt it to various usages and conditions. Thepreceding preferred specific embodiments are, therefore, to be construedas merely illustrative, and not limiting the remainder of the disclosurein any way whatsoever, and that it is intended to cover variousmodifications and equivalent arrangements included within the scope ofthe appended claims.

In the foregoing, all temperatures are set forth in degrees Celsius and,all parts and percentages are by weight, unless otherwise indicated.

The invention claimed is:
 1. A process for catalytically crackinghydrocarbons comprising: feeding a hydrocarbon feed stream to an FCCreactor and contacting said hydrocarbon feed stream with catalyst tocatalytically crack said hydrocarbon feed stream to provide a crackedstream; disengaging said catalyst from said cracked stream;fractionating said cracked stream into products including a slurry oilstream from a bottom of a main fractionation column; separating saidslurry oil stream in a separator into a cycle oil stream and a heavystream under vacuum pressure, comprising condensing a separator overheadstream from an overhead of said separator, separating said condensedoverhead stream in a receiver and taking said cycle oil stream from abottom of said receiver; and hydrocracking at least a portion of saidcycle oil stream over hydrocracking catalyst to provide an upgradedstream.
 2. The process of claim 1 further comprising heating said slurryoil stream before the separation step.
 3. The process of claim 1 furthercomprising recycling a portion of said heavy stream to said separationstep.
 4. The process of claim 3 further comprising recycling a portionof said heavy stream from a separator bottoms line to a recycle inletthat is above an inlet of said slurry oil stream to said separator. 5.The process of claim 4 further comprising pulling a vacuum on a receiveroverhead stream from said receiver and feeding it to a drain drum. 6.The process of claim 5 further comprising refluxing a portion of saidcycle oil stream to said separator to a reflux inlet that is above saidrecycle inlet.
 7. The process of claim 1 wherein said hydrocracking stepis conducted in a hydrocracking reactor in which hydrocracking is thepredominant reaction.
 8. The process of claim 7 further comprisingincreasing a yield of diesel compared to a yield without hydrocrackingsaid cycle oil stream.
 9. A process for catalytically crackinghydrocarbons comprising: feeding a hydrocarbon feed stream to an FCCreactor and contacting said hydrocarbon feed stream with catalyst tocatalytically crack said hydrocarbon feed stream to provide a crackedstream; disengaging said catalyst from said cracked stream;fractionating said cracked stream into products including a slurry oilstream from a bottom of a main fractionation column; heating said slurryoil stream; separating said slurry oil stream into a separator overheadstream and a heavy stream under vacuum pressure in a separator vessel;condensing said separator overhead stream; separating said condensedoverhead stream in a receiver; taking said cycle oil stream from abottom of said receiver; and hydrocracking at least a portion of saidcycle oil stream over hydrocracking catalyst to provide an upgradedproduct stream.
 10. The process of claim 9 further comprising recyclingsaid heavy stream to said separation step.
 11. The process of claim 10further comprising recycling a portion of said heavy stream from abottom of said separator vessel to a recycle inlet that is above aninlet of said slurry oil stream to said separator vessel.
 12. Theprocess of claim 9 further comprising pulling a vacuum on a receiveroverhead stream from said receiver and feeding it to a drain drum. 13.The process of claim 11 further comprising refluxing a portion of saidcycle oil stream to said separator vessel to a reflux inlet that isabove said recycle inlet.
 14. The process of claim 9 wherein saidhydrocracking step is conducted in a hydrocracking reactor in whichhydrocracking is the predominant reaction.
 15. The process of claim 9further comprising increasing a yield of diesel compared to a yieldwithout hydrocracking said cycle oil stream.
 16. A process forcatalytically cracking hydrocarbons comprising: feeding a hydrocarbonfeed stream to an FCC reactor and contacting said hydrocarbon feedstream with catalyst to catalytically crack said hydrocarbon feed streamto provide a cracked stream; disengaging said catalyst from said crackedstream; fractionating said cracked stream into products including aslurry oil stream from a bottom of a main fractionation column;separating said slurry oil stream into a cycle oil stream and a heavystream under vacuum pressure in a separator vessel, comprisingcondensing a separator overhead stream from said separator vessel;separating said condensed overhead stream in a receiver; and taking saidcycle oil stream from a bottom of said receiver; recycling said heavystream to said separation step; and hydrocracking at least a portion ofsaid cycle oil stream over hydrocracking catalyst to provide an upgradedproduct stream.
 17. The process of claim 16 further comprising pulling avacuum on a receiver overhead stream from said receiver.